November 6, 2013 DRWG | Holyoke, ma

1. November 6, 2013 DRWG | Holyoke, ma Doug Smith Manager of demand resource administration Review of requirements DR Metering Configurations

2. Overview • ISO has recently noticed several issues relating to metering configuration requirements • Required data is not being submitted in some cases • Conversations with some participants indicates a poitential lack of understanding of requirements and/or the reasons for them • A review and discussion of allowable configurations may be helpful • Material is sourced from the RA-DR training that was offered on Oct. 30

3. Overview of the Configurations • Facility Metered Load (FML) is the electricity used at a facility purchased from the grid • Total Facility Load (TFL) is the total electricity used at a facility inclusive of that purchased from the grid and that produced by on-site Distributed Generation (DG) • Only one asset at a facility can use either TFL or FML-based metering configurations • TFL and FML metering configurations cannot coexist at a facility • TFL = FML + Distributed Generation

4. Types of Metering

5. Meter Configuration Matrix For RTDR and RTEG Assets, real-time 5 minute interval data is required

6. (A) Load Reduction Only With No DG at the Facility RTDR • M1 required to submit 5-Minute telemetry through CFE/RTU • Customer Baseline (CB) is calculated and based on M1 (FML) • Average Hourly Load Reduction (HR) is CB-M1 M1 Facility RTDRAsset 123

7. (B) DG Output Directly Metered • RTDR, RTEG • M1 required to submit 5-Minute telemetry through CFE/RTU. Average Hourly Output (HR) is M1 • If pushback is possible, M2 required to submit hourly data through SMS or 5-Minute data through CFE/RTU • On-Peak, Seasonal Peak • M1 required to submit hourly data through SMS, though M&V requirement is to have at least 15 minute interval data. HR is M1 • If pushback is possible, M2 required to submit hourly data through SMS • No CB calculated M2 Facility M1 DGAsset 456

8. (C) DG Only Used to Reduce Load at the Asset • This metering configuration only applies to the RTEG DR Type where the EG is the only measure at the facility • M1 required to submit 5-Minute telemetry through CFE/RTU • CB is calculated and based on M1 (FML) • HR is CB – M1 • From a data stream, CB and HR perspective, this metering configuration is like “Load Reduction Only with no DG at the facility” (A) M1 Facility RTEGAsset 456

9. (D) Load Reduction Only With Directly Metered DG Used to Reduce Load at Another On-Site Asset RTDR – Asset 123 • M1 and M2 required to submit 5-Minute telemetry through CFE/RTU. • CB is calculated and based on M1 and M2 (TFL) • HR is CB – TFL RTDR/RTEG/On-Peak/Seasonal Peak – Asset 789 • Uses the MC of “DG Output Directly Metered” (B) noted earlier • For RTEG, MC of “DG only Used to Reduce Load at the Asset ” (C) at the Asset would not be allowed for this facility as there is another measure M1 Facility RTDRAsset 123 M2 DGAsset 789

10. (E) DG Used to Reduce Load at the Asset and Directly Metered DG at Another On-Site Asset RTEG Only • M1, M2 required to submit 5-Minute telemetry through RTU • CB is calculated and based on M1 and M2 (TFL) • HR is CB – TFL M1 Facility M2 DGAsset 789 DGAsset 456

11. (F) Load Reduction Pursuant to M&V Plan On-Peak, Seasonal Peak • Asset 789 submits demand reduction values across performance hours in each month • No CB is calculated Facility PassiveAsset 789

12. Changes to Metering Configurations • Once established, the metering configuration of a measure can only change with the addition of another measure at the same facility or when directly metering RTEG that was formerly DG used to reduce load • Upon receipt of a second measure registration, ISO will coordinate the metering configuration change with the Lead Market Participant(s)

13. Metering Configuration Considerations • Beginning with full integration of RTDR with the energy market (planned for June 2017), TFL configuration goes away in all cases except when there is an RTDR and RTEG at the same facility • Only one RTDR type asset will exist behind a retail delivery point • Metering and FML based performance at the Retail Delivery Point is required • This is required now for assets participating in Transitional Demand Response • Consideration should be given to utilizing Retail Delivery Point metering for any new assets being registered

15. Availability Forecasting • Control room operators need to know how much performance they should expect from these and other dispatchable resources in any given hour in order to reliably operate the system in real time. • Requirement for DR is that hourly forecasted demand reduction be provided for the next two operating days • This is entered through the DRMUI • This should reflect the expected reduction if the resource is dispatched to its full net CSO, and may be higher or lower than that CSO

16. Winter Reliability Program for DR • Part of the overall Winter Reliability Solution (Appendix K) • For RTDR (no RTEG) asset with at least 100 KW reduction, capacity must be in excess of any resource CSO • Runs from 12/1/2013 to 2/28/2014 • Allows accepted assets to be dispatched by operator from 0500 to 2300 7 days a week • Commitment for initial 10 dispatches; additional performance optional if dispatched • Dispatched by phone call from operator to DDE • Dispatch will be prior to or coincident with OP4 Action 2 • Audit will be coincident with the seasonal audit of RTDR capacity Resource the Assets are mapped to